Feeder Terminal. REF 542plus. Product Guide

Transcription

1 Product Guide

2

3 Issued: January 2007 Status: New Version A/ Data subject to change without notice Features Real-time multifunction protections and switchgear controls: - protections - measurements - controls - monitoring and diagnosis - power quality functions - communication - self diagnosis Task separation for implemented protections and control scheme modifications Flexible installation variations due to separated HMI and base unit Large multilingual LCD display for singleline diagram, text messages and menu texts Calculated primary quantities include: - maximum and mean currents in the settable monitoring period 0-30 min - sum of interrupted currents - operating time - number of switching cycles Spring charging time supervision Trip coil supervision Binary input and output modules to interface with external processes Analog input module for primary current and voltage signals: - analog transformers - non-inductive sensors Optional analog input module 4-20 ma Optional analog output module 0(4)-20 ma Optional communication module for the substation automation system Ethernet interface for embedded web server Optical input port for time synchronization Part of the ABB Distribution Automation system General The Feeder Terminal is a compact protection, control, measurement and supervision terminal for the power distribution system. The same terminal can be used for feeder, transformer and motor protection and control, or solely for switchgear control. The terminal features an impressive range of protection and management functions readily available for adapting the unit to the intended application. The versatility of the REF 542plus terminal makes it a given solution for any air or gas insulated distribution substation switchgear as shown in figure 1 and in figure 2. Fig. 1 installed in gas-insulated switchgear (GIS). A

4 General (cont d) Fig. 2 installed in an air-insulated switchgear (AIS). A is composed of two parts: a base unit and a separate human machine interface (HMI). The base unit contains the power supply, the processor board, the analog input board and binary input and output (I/O) modules, as well as optional modules for supplementary functions. The base unit and a HMI are connected with a serial cable. Block diagram Analog Output Module Analog Input Module Communication Module 0/4...20mA 0/4...20mA RX TX CP Communication n PProcessor Analog Input Module IL1 IL2 IL3 UL1 UL2 UL3 Io Vo DSP Protection Measurement start L1 start L2 start L3 Release/Trip Autoreclosure CAN Eth. µc Control Time Synch. Main Board Binary inputs Binary outputs Binary Input Output Module(s) A c A Fig. 3 block diagram. HMI The HMI is a stand-alone unit with its own power supply. It can be installed on the low voltage (LV) compartment door or in a dedicated compartment close to the base unit. The HMI can be used to set the protection parameters to locally operate the switching devices in the switchgear and to visualize events and measurements. A shielded, isolated twisted pair according to the RS-485 standard interface connects the HMI to the base unit. Fig. 4 shows an installation of the base unit and the HMI control unit in the LV compartment. 4

5 General (cont d) Fig. 4 Mounting of the base unit in the LV compartment and the HMI on the door. A The HMI control unit, Fig. 5, features a backilluminated liquid crystal display (LCD), eight push buttons, several LEDs and an electronic key interface. The language of the display can be selected by using the related software on the Configuration Tool CD (1MRS151062). The same software is also used to define the protection and the control scheme. Fig. 5 HMI control unit. A The left side of the LCD display is reserved for the single line diagram. The right side is for plain text visualization such as measurement and protection events. The LCD backlight is switched off automatically after 20 minutes of inactivity. The HMI is a complete system for the local management of the switchgear. The HMI allows the operator to set the protection functions, operate the primary objects, visualize measurements and events, reset alarms and change the unit working mode. 5

6 Application Monitoring and self-diagnosis The offers several features for monitoring the primary part as well as selfdiagnosis. The following computed quantities are available for primary part monitoring: maximum and mean currents in the observation period ( min) sum of interrupted currents operating time number of switching cycles (open-close circuit breaker) spring charging time supervision (when applicable) trip coil supervision The is equipped with self-diagnosis routines that constantly check the hardware and software modules status. Every binary input and output module is equipped with a watchdog contact that triggers in case of fault or power loss. This contact can be used to detect unit failure and to initiate the appropriate actions. Analog input channels can be optionally supervised. A broken wire in the connection with an instrument transformer or a sensor can be detected and an alarm can be activated. Protection offers a wide range of functions for protection. As previously mentioned, a wide range of protection schemes for the protection of several system components can be configured. The available protection functions depend on the ordered software licenses. The licenses are Basic Low, Basic, Multi Low, Multi, Differential and Distance. In table 20 the corresponding provided protection functions are listed. Current protection: inrush blocking (68) overcurrent instantaneous (50) overcurrent definite time, 2 thresholds (51) overcurrent directional, 2 thresholds (67) overcurrent IDMT (51 IDMT) earth fault, 2 thresholds (51N) earth fault IDMT (51 IDMT) earth-fault directional, 2 thresholds (67N) earth-fault directional sensitive (67S) earth-fault directional sector (67NS), 10 thresholds. Voltage protection: overvoltage instantaneous (59) overvoltage definite time, 2 thresholds (59) undervoltage Instantaneous (27) undervoltage definite time, 2 thresholds (27) residual overvoltage, 2 thresholds (59N) Line protection: distance protection (21) Differential protection: differential protection for motors and transformer (87) restricted earth-fault for transformer (87N) Thermal protection: for cables, motors and transformers (49) Motor-specific protection: number of starts counting (66) locked rotor (51LR) motor start (51MS) low load (37) unbalanced load (46) Power quality mitigation: power factor controller (55) switching resonance protection high harmonics protection Other protections and related functions: frequency protection (81), 6 thresholds per net synchro check (25) fault recorder autoreclosure (79) directional power (32). At most 24 protection functions can be installed inside the unit. The maximum number is anyway dependent upon the available processing power. 6

7 Control The control and automation capabilities of the are extremely powerful. Comprehensive PLC functionalities are foreseen. Simple interlocking against switching errors as well as complex loadshedding schemes can be easily implemented in the. Even protection similar functionalities, like e.g. circuit breaker failure protection or signal comparison scheme can be programmed. Fault recorder The unit is equipped with a powerful and flexible fault recorder function. This function can be used to record at most eight analog input channels and thirty-two binary signals. The analog input signals are recorded with a sampling rate of 1.2 khz for a time interval of at least 1 second and for a maximum of 5 seconds. The recording time is a combination of pre- and post-fault time. The total recording capability is 5 seconds. It can be configured 5 records of 1 seconds or a single record of 5 seconds. The recording can be started by a protection event, by a binary signal change or by any user-defined condition. Fault records can be transferred locally to a personal computer from the HMI front port by using the Operating Tool or remotely from the communication interface. When uploaded with the Operating Tool the fault records are automatically converted into the standard COMTRADE format. When the fault records retrieve from the communication interface, they can be converted with a utility program. Fault records are stored in non-volatile memory, so they remain available also after a power failure. 7

8 Design Software design Analog inputs switchbay feeder terminal is designed for connecting to non-conventional current and voltage sensors as well as to instrument transformers. At most 8 analog input channels are available. Due to their linear characteristic, modern current and voltage sensors provide greater accuracy and reliability in signal measurements. Compared to instrument transformers, the new non-inductive sensors have the following advantages: higher linearity high accuracy compact dimensions wide dynamic range easy integration in the panels. The current sensor is based on the Rogowsky coil principle and consists of a single airwounded coil. Due to the lack of an iron core, the saturation effects of conventional current transformers do not exist anymore. Current sensors are thus well suited for the deployment of distance and differential protection functions. The voltage sensor is based on the resistive divider principle. Therefore, the voltage sensor is linear throughout the whole measuring range. The output signal is a voltage, directly proportional to the primary voltage. Binary inputs and outputs The unit acquires the primary objects status with auxiliary contacts, which are read by binary inputs, and sends commands using binary outputs. Several signals coming from other components are also monitored. Among others, the following operations are implemented using binary inputs and outputs: primary objects control and interlocking in the switchgear primary objects status acquisition (for example circuit breaker in opened/closed position) circuit breaker spring supervision (when applicable). Binary inputs are isolated by opto-couplers. Binary outputs can be implemented either with mechanical relays or with static (semiconductor) devices. In a switchgear with directly driven motors, static power outputs are usually required. Interfacing a station automation system An optional communication module can be provided for interfacing a station automation system. The four different protocols available for the make possible to interface any kind of station automation system, both from ABB or from third parties. The following typical functions are possible: primary objects status monitoring primary objects control protections parameterization measurements, alarms end events acquisition fault recorder data acquisition. The available protocols are: SPA ABB LON according to LON Application Guide (LAG) 1.4 definitions MODBUS RTU MODBUS TCP IEC with the extensions for control functions according to VDEW (Vereinigung Deutscher Elektrizitätswerke = Association of German Utilities) IEC (only vertical communication) The first two protocols, SPA and LON according to LAG 1.4, are ABB specific. The LON LAG 1.4 protocol has specific features for high accuracy time synchronization. In this case, the units are synchronized from the interbay bus. The other protocols, MODBUS RTU, MODBUS TCP and IEC guarantee open connectivity to any third party system. In case of communication to a Profibus DP control system is required, a corresponding gateway SPA-ZC 302 can be used. 8

9 Design (cont d) Hardware design Base unit versions The base unit housing is made from aluminum sheets. Its surface is chromatized both to protect the housing against corrosion and to improve immunity against EMC disturbances. Two different housings are available: Standard Wide In both versions, at least the following modules have to be present: the power supply, the mainboard. the analog input module one binary input and output module The standard housing can additionally include: another binary input and output module alternatively the communication module or the 0(4)-20 ma analog output module. Note: The backplane for the 0(4)-20 ma analog output module and the communication module is different, so the backplane will be varied according to the order. The wide housing can additionaly house: other 2 binary input and output modules the communication module alternatively the 0(4)-20 ma analog output module or the 4-20 ma analog input module Standard housing dimensions, see Fig. 6. M ,5 0, ,8 106,3 M4 106, ,1 12 ca , ,5 0,1 18 0,1 0,1 0,1 75,5 0,1 75,5 0,1 75,5 0,1 75,5 M4 Fig. 6 Standard housing version dimensions. A

10 10 233,5 0, ,5 97,5 106,3 244,8 97,5 97,5 M ,5 0,1 18 M4 106, ,1 12 ca , ,1 0,1 0,1 0,1 0,1 0,1 M4 Fig. 7 Wide housing version dimensions. A Mounting Fig. 8 shows an example of wide housing base unit installation inside a low voltage compartment. Fig. 8 Base unit installation in LV compartment of a GIS system. A

11 Mounting (cont d) HMI dimensions are illustrated in the Fig. 9 below. The upper one is the version of the HMI without cover and the lower one is with cover to achieve a better protection. A Fig. 9 HMI dimensions. A The advisable panel cut-out is 240,5 x 140,5 mm. (The existing connectors for the former HMI version can be used.) 11

12 Technical data Measurements The uses the same analog inputs both for measurements and protections. Table 1: Measurements Quantity Class Range Phase current, earth current x I n Line voltage, phase voltage x U n Active, reactive energy 2 - Active, reactive, apparent power 1 - Cos ϕ Frequency Table 2: Protection functions and operation time Quantity Range Protection functions Class 3 Operation time Class 3 or minimum ±15 ms Table 3: Current and voltage transformer input values Quantity Range Rated current I n 0.2 A, 1.0 A, 5.0 A Rated voltage U n V AC Rated frequency f n 50 Hz/60 Hz Table 4: Thermal load capacity Quantity Range Current path 250 x I n (peak value), 100 x I n for 1 s (dynamic ), 5 x I n (continuous) Voltage path 2 x U n / 3 (continuous) Table 5: Consumption Quantity Current path Voltage path Range <0.1 VA at I n <0.25 VA at U n Protection functions Table 6: ANSI code protection functions and parameters Current protection functions 68 Inrush stabilization (Only in connection with 50 and 51) N = M = Time = ms 68 Inrush harmonic Minimum current threshold = x I n Fault current threshold = x I n Harmonic ratio threshold = 5-50% 50 Overcurrent instantaneous I>>> = x I n t = ms 51 Overcurrent high I>> = x I n t = ms 51 Overcurrent low I> = x I n t = ms 51 IDMT Overcurrent IDMT (Inverse Definite Minimum Time) Inverse time characteristics: Normal, Very, Extreme and Long-time inverse I e = x I n K =

13 Technical data (cont d) Table 6: ANSI code protection functions and parameters 67 Overcurrent directional high I>> = x I n t = ms Direction = backward, forward 67 Overcurrent directional low I>> = x I n t = ms Direction = backward, forward Earth fault (1) 51N Earth-fault high I 0 >> = x I n t = ms 51N Earth-fault low I 0 > = x I n t = ms 51N IDMT Earth-fault IDMT Inverse time characteristics: Normal, Very, Extreme or Long-time inverse I e = x I n K = N Earth-fault directional, high I 0 >> = x I n t = ms U 0 = x U n Direction = forward, backward Net type = isolated (sin ϕ), earthed (cos ϕ) 67N Earth-fault directional, low I 0 > = x I n t = ms U 0 = x U n Direction = forward, backward Net type = isolated (sin ϕ), earthed (cos ϕ) 67S Earth-fault directional, sensitive I 0 = x I n t = ms Angle alpha = o Angle delta = o o U 0 = x U n 67N Sector Earth-fault directional, sector (10 thresholds available) Direction = enable/disable directional behavior Start criteria = neutral current magnitude/ neutral current basic angle I 0 = x I n U 0 = x U n t = ms Sector basic angle = o o Sector width = o I 0 drop off delay = ms U 0 drop off delay = ms Voltage protective functions 59 Overvoltage, instantaneous U>>> = U n t = ms 59 Overvoltage, high U>> = U n t = ms 59 Overvoltage, low U> = U n t = ms 27 Undervoltage, instantaneous U<<< = U n t = ms 27 Undervoltage,high U<< = U n t = ms 27 Undervoltage, low U< = U n t = ms 25 Synchronism check Delta Voltage = U n Delta phase = 5-50 Time = s 59N Residual overvoltage, high U NE > = U n t = ms 59N Residual overvoltage, low U NE > = U n t = ms 13

14 Technical data (cont d) Table 6: ANSI code protection functions and parameters Motor protection functions 49 Thermal overload protection with total memory Nominal temperature = C (nominal temperature at I n ) Nominal current (I Mn ) = x I n (primary value of the nominal motor current) Initial temperature = C Time constant at I <0.1 x I Mn = s Time constant at 0.1 x I Mn < I <2 x I Mn = s Time constant at I >2 x I Mn = s Trip Temperature = C Warning temperature = C Environmental temperature = C Reset temperature = C 51 MS Motor start I Mn = x I Mn (motor current) I s = x I Mn (start value) t = ms I> = x Is (motor start) 51 LR Locked rotor (definite time characteristic) I Mn = x I n (motor current) I s = x I Mn (start value) t = ms 66 Number of starts n (warm) = 1-10 (number of warm starts) n (cold) = 1-10 (number of cold starts) t = s T (warm) = C (warm start temperature thereshold) 46 Unbalance load I s = x I n (start value of the negative phase sequence) K = t Reset = s Timer decreasing rate = 0-100% 37 Low load P n = kw (primary values) Minimal load P = 5-00% x P n Minimal current I = 2-20 % x I n Operation time = s Differential protection functions 87 Differential Differential Transformer group = 0-11 Transformer earthing = primary and or secondary side Primary nominal current = A (prim value) Secondary nominal current = A (prim value) Threshold current = x I r (p.u.) Unbiased region limit = x I r (p.u.) Slightly biased region threshold = x I r (p.u.) Slightly biased region limit = x I r (p.u.) Slope = Trip by I d > = x I n Blocking by 2nd harmonic = x I n Blocking by 5th harmonic = x I n 87N Restricted earth fault protection (restricted differential) Reference nominal current = A Unbiased region threshold= x I r Unbiased region limit = x I r Slightly biased region slope = Slightly biased region limit = x I r Heavily biased region slope = Relay operate angle = t = s 14

15 Technical data (cont d) Table 6: ANSI code protection functions and parameters Frequency protection function 81 Frequency protection Start value = Hz, step 0.01 Hz Frequency gradient = Hz/s t = s U< = U n Trip logic = frequency only frequency AND freq. gradient frequency OR freq. gradient Frequency supervision Frequency supervision Start value = Hz Time = s Distance protection function 21 Distance protection Net type = high/low ohmic Earth start I E > = used, unused Switching onto faults = normal, overreach zone, trip after start Signal comparison overreach scheme time set = ms U/I -start characteristic I>, I E > and I F > = x I n U F < = x U n Phase selection = cyclic or acyclic Earth factor Factor k = , Angle (k) = Impedance, 1 overreach stage, and 1 autoreclose control stage: Power quality functions Power factor controller R = Ohm (secondary values) X = Ohm (secondary values) t = ms Angle delta 1 = Angle delta 2 = t = ms 1 non directional stage t = ms Switching sequence = linear or circular Switching histeresis,neutral zone = % x Q co Pick up value = 0-100% x Q co Reactive power of smallest bank Qc o = kvar Configuration banks: 1:1:1:1, 1:1:2:2, 1:2:2:2, 1:2:4:4, 1:2:4:8 Number of banks = 1-4 Max. switching cycles = Set point cos ϕ = ind. or cap. Limiting value cos ϕ = ind. or cap. Method of operation = direct, integrating Discharge blocking time = s Dead time = s Power on delay = s Duration of integration = s High harmonic protection Voltage THD start value = 5-50% Voltage THD time delay = s Time = s RMS voltage start value = U n Switching resonance protection Voltage THD start value = 5-50% Delta voltage THD start value = 1-50 % Voltage THD time delay = s t = s PFC OP time = s RMS voltage start value = U n 15

16 Technical data (cont d) Table 6: ANSI code protection functions and parameters Other functions Fault recorder Time before fault = ms Recording time = ms Time after fault = ms Max. 5 records 79 Autorecloser Operation mode = Start and Trip controlled, Start Controlled Number of reclosing cycle = Reclaim time = s Specific/operation time 1st shot = s Dead time1st shot = s Specific/operation time 2nd shot = s Dead time 2nd shot = s Specific/operation time 3rdshot = s Dead time 3rd shot = s Specific/operation time 4th shot = s Dead time 4th shot = s Specific/operation time 5th shot = s Dead time 5th shot = s 32 Directional power Direction = forward, backward Nominal real power P n = kw (primary values) Max. reverse load P> = 1-50% x P n Operation time = s 16

17 Typical connection diagrams This picture represents a typical connection scheme for outgoing feeders when voltage and current protections are required. There is also a current balance transformer for earthfault current sensing. Analog input channel no. 8 is not used. Fig. 10 Generic outgoin feeder A

18 Typical connection diagrams (cont d) The schematic diagram below shows a connection for a power transformer feeder with differential, earth-fault and restricted earthfault protections. The used analog input board has 8 inputs for currents. Channels 1-6 are for the differential protection, channel 7 is used for the restricted earth-fault protection and channel 8 for the earth-fault protection. L1 L2 L3 Q1 X80 11 S1 7 3 AI1 TI/L1 S2 22 TI/L2 S1 S AI2 S1 10 TI/L3 S2 6 AI3 2 S1 S2 S AI4 TI/L1 S2 5 TI/L2 S1 S2 9 1 AI5 S1 23 TI/L3 S AI AI AI8 4 Fig. 11 Power transformer differential protection A

19 Typical connection diagrams (cont d) The Fig. 12 shows a possible connection diagram for a generic incoming feeder with synchrocheck function on the busbar. Channels 1-3 are used for current sensing and channels 4-6 are used for phase to earth voltage measurements and protection of the incoming feeder. Channel 7 is used for the residual current for earth-fault protection and channel 8 is used for the busbar phase-tophase voltage to perform the synchrocheck. L1 L2 L3 X80 11 (1A) TI/L1 S1 S2 7 (5A) 3 AI1 22 (1A) TI/L2 S1 S2 18 (5A) 14 AI2 10 (1A) TI/L3 S1 S2 6 (5A) 2 AI3 TV1/L1 A N AI4 TV2/L2 A N 5 1 AI5 TV3/L3 A N AI6 24 (1A) 20 (5A) AI AI8 Fig. 12 Incoming feeder with synchrocheck capability. A

20 Ordering The different variants have their own specific order numbers that identify the type designation for the desired hardware and software combination. The type code designation can be seen in Fig. 13 Fig. 13 Type code designation for ordering. TA Each code is dedicated to a specific application or module. The description for each type code is listed in the following tables. The codes mentioned below are mostly used for operations field. For DNV and ATEX the codes are slightly different. Because ATEX certification is only valid for a specific version of the, it is required, after each new release to obtain a new certification. The release 1.1 of ATEX certified units are with version V4C02 and the release 2.2 with version V4D02. ATEX certified units with these release version will be delivered with the former version of the HMI V4. The DNV certification is meant for marine application. 7 6 B 6 A S Z 4 1 Table 7: Family code Number Code Name Description 7 Product family for the feeder terminal unit 7 6 B 6 A S Z 4 1 Table 8: Application areas Number Code Name Description 6 Normal operation A DNV Marine and offshore application B ATEX-1 Motor protection in explosive area (Rel. 1.1) C ATEX-1+DNV Marine application in explosive area (Rel. 1.1) D ATEX-2 Motor protection in explosive area (Rel. 2.0) E ATEX-2+DNV Marine application in explosive area (Rel. 2.0) 7 6 B 6 A S Z 4 1 Table 9: Main board versions Number Code Name Description B /802 Basic Version with RJ 45 Ethernet port S /803 Standard Version with additional IRIG B and CAN interface F /801 Full Version with additional optical links 20

21 Ordering (cont d) 7 6 B 6 A S Z 4 1 Table 10: Power supply versions Number Code Name Description /801 U n = 110 V DC For applications with rated voltage 110 V DC /802 U n = 220 V DC For applications with rated voltage 220 V DC /801 U n = V DC For applications with rated voltage V DC /802 U n = V DC, DNV version 7 6 B 6 A S Z 4 1 Table 11: Analog I/O modules 7 6 B 6 A S Z 4 1 For marine applications with rated voltage V DC Number Code Name Description N none No analog input or Empty analog I/O module slot output A /801 Analog input module 4-20 ma B /801 Analog output module 0(4) - 20 ma Table 12: Binary I/O modules Analog input module for 4-20 ma installed, up to 6 inputs Analog output module for 0(4) - 20 ma installed, up to 4 outputs Number Code Name Description /801 Static I/O Application in GIS panel with coil supervision by control continuity check /802 Static I/O without control continuity check Static I/O without control continuity check /801 Binary I/O V/ 14 V DC, standard /803 Binary I/O V/ 14 V DC, with static channel /801 Binary I/O V /14 V DC, interconnected input, standard /803 Binary I/O V/ 14 V DC, interconnected input, with static channel /802 Binary I/O V/ 50 V DC, standard A /804 Binary I/O V/ 50 V DC, with static channel B /802 Binary I/O V/ 50 V DC, interconnected input, standard C /804 Binary I/O V/ 50 V DC, interconnected input, with static channel Standard version with 14 V DC treshold value for application in auxiliary circuit with DC voltage range V DC As no. 5 + one static output channel for energy metering As no. 5 + interconnected binary inputs As no. 5 + interconnected binary inputs + one static output channel for energy metering Standard version with 50 V DC treshold value for application in auxiliary circuit with DC voltage range V DC As no. 9 + one static output channel for energy metering As no. 9 + interconnected binary inputs As no. 9 + interconnected binary inputs + one static output channel for energy metering 21

22 Ordering (cont d) Table 12: Binary I/O modules Number Code Name Description D /805 Binary I/O V/ 72 V DC, standard E /806 Binary I/O V/ 72 V DC, with static channel F /807 Binary I/O V/ 143 V DC, standard G /808 Binary I/O V/ 143 V DC, with static channel Standard version with 72 V DC treshold value for application in auxiliary circuit with DC voltage range V DC As no. D + one static output channel for energy metering Standard version with 143 V DC treshold value for application in auxiliary circuit with DC voltage range V DC As no. F + one static output channel for energy metering Static I/O: 14 inputs, 7 power outputs, 2 signal outputs and 1 watchdog output. BIO 3: 14 inputs, 6 power outputs, 2 signal outputs and 1 watchdog output. 7 6 B 6 A S Z 4 1 Binary IO Slot 2: Version of binary I/O, the possible selection depends on the selected version of binary I/O 1. If no binary I/O is needed, the slot can be left empty. The corresponding code can be taken from the table B 6 A S Z 4 1 Binary IO Slot 3: Version of binary I/O, the possible selection depends on theselected version of binary I/O 1. If no binary I/O is needed, the slot can be leftempty. The corresponding code can be taken from the table B 6 A S Z 4 1 Analog Input XX: There are three different types of analog input version which canbe selected as shown in the following tables: Table 13: Sensors Number Code Description /803 Analog Input sensors version Table 14: Mix of sensors and transformers Number Code Description /843 3 sensors + 3 sensors + 1 CT/0.2 A + 1 VT /846 3 sensors + 3 VT + 1 CT/0.2 A + 1 VT /847 3 sensors + 3 sensors + 1 CT /851 3 sensors + 3 sensors + 1 CT+ 1 VT /852 3 sensors + 3 sensors + 1 CT/0.2 A /853 3 sensors + 3 sensors + 1 VT + 1 VT /854 3 sensors + 3 CT + 1 CT/0.2 A + 1 VT /855 3 sensors + 3 CT + 1 CT/0.2 A + 1 CT/0.2 A 22

23 Ordering (cont d) Table 15: Mix of transformers Number Code Description /804 3 CT + 3 VT + 1 CT/0.2 A + 1 VT /806 3 VT + 3 VT + 1 CT/0.2 A + 1 CT/0.2 A /807 3 CT + 3 CT /809 3 CT + 3 CT + 1 CT/0.2 A+ 1 VT /812 3 VT + 3 VT + 1 VT /817 3 CT + 3 VT + 1 CT /819 3 CT + 3 VT + 1 CT + 1 VT /821 3 CT + 0 VT + 1 CT /822 3 CT + 0 VT + 1 CT/0.2 A /825 3 CT + 3 VT + 1 CT/0.2 A + 1 CT/0.2 A /826 3 CT + 3 VT + 1 VT + 1 VT /827 3 CT + 3 CT + 1 CT + 1 CT /828 3 CT + 3 CT + 1 CT + 1 VT /824 3 CT + 3 VT + 1 CT + 1 CT 7 6 B 6 A S Z 4 1 Table 16: Communication (With optional coomunication module) Number Code Name Description N None Without communication No communication is requested /801 Modbus RTU / SPA RS /802 Modbus RTU / SPA glass fibre with ST connectors /801 SPA plastic fibre /802 SPA glass fibre with SMA connectors /803 SPA glass fibre with ST connectors /801 LON-LAG /803 IEC E 1VCR IEC with RJ45 F 1VCR IEC with LC optical connector 7 6 B 6 A S Z 4 1 Table 17: Enclosure versions Number Code Name Description S /801 Normal base unit Normal version W /801 Wide base unit Wide version 23

24 Ordering (cont d) 7 6 B 6 A S Z 4 1 Table 18: HMI variations Number Code Name Description N none No HMI A /003 HMI V5 1) - IEC, auxiliary voltage V DC B /004 HMI V5 - IEC, auxiliary voltage V DC C /007 HMI V5 - IEC, external cover, auxiliary voltage V DC D /008 HMI V5 - IEC, external cover, auxiliary voltage V DC E /011 HMI V5 - IEC, Chinese, auxiliary voltage V DC F /012 HMI V5 - IEC, Chinese, auxiliary voltage V DC G /015 HMI V5 - IEC, Chinese, external cover, auxiliary voltage V DC H /016 HMI V5 - IEC, Chinese, external cover, auxiliary voltage V DC /801 HMI V4 2) V DC /802 HMI V V DC /805 HMI V V DC, ANSI /806 HMI V V DC, ANSI 1) V5 = With Unicode fonts, 2) V4 = With character map. 7 6 B 6 A S Z 4 1 Table 19: Connection cables between the HMI and the base unit 1) Number Code Name Description N none No cable No cable /801 HMI cable m 1.8 m cable with corresponding connectors /817 HMI cable m 2.5 m cable with corresponding connectors /818 HMI cable m 3.5 m cable with corresponding connectors /819 HMI cable m 4.5 m cable with corresponding connectors 24

25 Ordering (cont d) 7 6 B 6 A S Z 4 1 Table 20: Software licenses 1) Number Code Name Description 1 1MRS Software base license Software level : Base 2 1MRS Software high license Software level : High 3 1MRS Software basic low license Software level : Basic Low 4 1MRS Software basic license Software level : Basic 5 1MRS Software multi low license Software level : Multi Low 6 1MRS Software multi license Software level : Multi 7 1MRS Software differential license Software level : Differential 8 1MRS Software distance license Software level : Distance 1) Limitation of protection functionality by software license. Please contact your local ABB organization for more detailed information. Software level Base can only be ordered by ABB switchgear companies and is the same level as software level Distance. Table 21: SW tool licenses Code 1MRS MRS Description Operating Tool CD Configuration Tool CD 25

26 Ordering (cont d) Please use the key below to generate the type designation. The code numbers in the following example are not complete and should be taken from the corresponding tables above. 7 6 B 6 A S Z 4 1 Software SW level: 1 = Base 2 = High 3 = Basic low (For more information, see Table 20) Connection cable N = None 1 = 1.8 m cable 2 = 2.5 m cable (For more information, see Table 19) HMI N = None A = HMI V5 for IEC, V DC B = HMI V5 for IEC, V DC C = HMI V5 for IEC, V DC, with cover (For more information, see Table 18) Enclosure S = Normal W = Wide (For more information, see Table 17) Communication N = No communication 1 = Modbus/SPA RS485 2 = Modbus/SPA glass fibre, ST connector (For more information, see Table 16) Analog input 01 = Sensors = Mixed sensors and transformers = Mixed transformers (For more information, see Tables 13-15) Binary I/O 1 1 = Static I/O 2 = Static I/O without check 3 = Binary I/O vers. 3 (For more information, see Table 12) Binary I/O 2 and Binary I/O 3 (For more information, see page 22) Analog I/O modules N = No I/O module A = Analog input module 0(4) - 20 ma B = Analog output module 4-20 ma (For more information, see Table 11) Power supply 1 = 110 V DC 2 = 220 V DC 3 = V DC 6 = V DC, DNV/marine (For more information, see Table 10) Main board B = Basic S = Standard (For more information, see Table 9) Applications 6 = A =, DNV/marine B =, ATEX-1 C =, ATEX-1 + DNV/marine (For more information, see Table 8) Feeder terminal family code 7 = (For more information, see Table 7) A b Fig. 14 The key for generating the type designation 26

27 References Table 22: Product documentation Name of the manual Installation and Commission (Manual Part 3), Operator's Manual, Technical Reference Manual Protection Functions, Configuration and Settings Communication (Manual Part 4) Modbus RTU, Technical Reference Configuration and Operating Tool, User's Guide IRIG-B Input Time Master, Application Guide CAN Manual ibutton Programmer User's Guide Motor Protection with ATEX-Certification, Appl.Guide Web Interface, Installation Manual Web Interface, Operator's Manual Document ID 1VTA MRS MRS MRS VTA MRS MRS MRS VTA Rev 1, en 1MRS MRS MRS MRS

28 ABB Oy Distribution Automation P.O. Box 699 FI Vaasa, FINLAND Tel Fax